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Academic literature on the topic 'Enbridge Pipelines (NW) Inc'
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Books on the topic "Enbridge Pipelines (NW) Inc"
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Board, Canada National Energy. Reasons for decision in the matter of Enbridge Pipelines Inc. Calgary, AB: National Energy Board, 2008.
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Board, Canada National Energy. Reasons for decision in the matter of Enbridge Southern Lights GP on behalf of Enbridge Southern Lights LP and Enbridge Pipelines Inc. Calgary, AB: National Energy Board, 2008.
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Board, Canada National Energy. Reasons for decision in the matter of Enbridge Pipelines Inc. line 4 extension project. Calgary, AB: National Energy Board, 2008.
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Enbridge Pipeline Oil Spill in Marshall, Michigan: Hearing before the Committee on Transportation and Infrastructure, House of Representatives, One Hundred Eleventh Congress, second session, September 15, 2010. Washington: U.S. G.P.O., 2010.
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Answer Is Still No: Voices of Pipeline Resistance. Fernwood Publishing Co., Ltd., 2014.
Find full textConference papers on the topic "Enbridge Pipelines (NW) Inc"
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Doblanko, Rick M., James M. Oswell, and Alan J. Hanna. "Right-of-Way and Pipeline Monitoring in Permafrost: The Norman Wells Pipeline Experience." In 2002 4th International Pipeline Conference. ASMEDC, 2002. http://dx.doi.org/10.1115/ipc2002-27357.
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Enbridge Pipelines (NW) Inc. (Enbridge) owns and operates a 323.9 mm outside diameter crude oil pipeline from Norman Wells, Northwest Territories, Canada to Zama, Alberta, Canada (Norman Wells Pipeline). The first of its kind in North America, this pipeline, completely buried in discontinuous permafrost, is approximately 869 kilometres in length. The pipeline, designed to operate at ambient temperatures, was constructed during the winter seasons of 1983–1984 and 1984–1985 and began operations in April 1985. Enbridge (formerly Interprovincial Pipe Line (NW) Ltd.), under various regulatory terms and conditions, is required to monitor and report the effects of pipeline construction and operations associated with the environment and right-of-way. The company has been an active participant in joint research and monitoring working groups consisting of various departments of the Government of Canada, Government of Northwest Territories, and other agencies. Over the past seventeen years, Enbridge has developed a monitoring and surveillance program that ensures the safe operation of the pipeline and protection of the environment. Any significant issues arising from the monitoring program result in mitigative actions based on engineering assessments. Furthermore, Enbridge is mandated to inform the appropriate agencies of issues resulting from the monitoring program. This paper will focus on the terrain and geotechnical monitoring programs initiated by Enbridge over its years of operation of this pipeline and will discuss topics including operations and maintenance activities key to pipelines installed in discontinuous permafrost, condition of the pipeline, and the on-going terrain and slope monitoring program.
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Wilkie, S. A., R. M. Doblanko, and S. J. Fladager. "Case History of Local Wrinkling of a Pipeline." In 2000 3rd International Pipeline Conference. American Society of Mechanical Engineers, 2000. http://dx.doi.org/10.1115/ipc2000-211.
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Enbridge Pipelines (NW) Inc. (formerly Interprovincial Pipe Line (NW) Ltd.) owns and operates a buried 323mm diameter crude oil pipeline from Norman Wells, NWT to Zama, AB. The pipeline is approximately 869 km in length, with the route following a portion of the Mackenzie River Valley in the Northwest Territories. The pipeline routing is through discontinuous permafrost that has the potential to interact with the pipeline through frost heave, slope movement and thaw settlement that can produce extreme structural stresses in the pipe wall. Given the proper conditions, these stresses may localize and the pipeline will deform plastically, causing pipe wall wrinkling. This paper reviews the general structural design and discusses the inspection and monitoring of the structural integrity of the pipeline, as well as the intervention criteria used to determine when structural mitigation is required. This case study will discuss the discovery of a wrinkle from internal inspection pig data, field dig verification, installation and monitoring of field instrumentation and the pipeline repair technique that was utilized.
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Burgess, Margo M., Scott Wilkie, Rick Doblanko, and Ibrahim Konuk. "Field Observations of Cyclical Pipe-Soil Interactions in Permafrost Terrain, KP 5, Norman Wells Pipeline, Canada." In 2000 3rd International Pipeline Conference. American Society of Mechanical Engineers, 2000. http://dx.doi.org/10.1115/ipc2000-119.
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The Norman Wells pipeline is an 869 km long, small diameter, buried, ambient temperature, oil pipeline operated by Enbridge Pipeline (NW) Inc. in the discontinuous permafrost zone of northwestern Canada. Since operation began in 1985, average oil temperatures entering the line have been maintained slightly below 0°C, initially through constant chilling year round and since 1993 through a seasonal cycling of temperatures through a range from −4 to +9°C. At one location, 5 km from the inlet at Norman Wells, on level terrain in an area of widespread permafrost, uplift of a 20 m segment of line was observed in the early 1990s. The uplift gradually increased and by 1997 the pipe was exposed 0.5 m above the ground surface. Detailed studies at the site have included field investigations of terrain and thermal conditions, repeated pipe and ground surface elevation surveys, and annual Geopig surveys. The field work has revealed that the section of line was buried in low density soils, thawed to depths of 4 m on-right-of-way, and not subjected to complete refreezing in winter. The thaw depths are related to surface or near-surface flows from a nearby natural spring, as well as to the development of a thaw bulb around the pipe in the cleared right-of-way. Icings indicative of perennial water flow occur commonly at this location in the winter. The pipe experienced annual cycles of heave and settlement (on the order of 0.5 m) due to seasonal freezing and thawing within the surrounding low density soils. The pipe reached its highest elevation at the end of each winter freezing season, and its lowest elevation at the end of the summer thaw period. Superimposed on this heave/settlement cycle was an additional step-like cycle of increasing pipe strain related to thermal expansion and contraction of the pipe. A remedial program was initiated in the winter of 1997–98 in order to curtail the cumulative uplift of the pipe, reduce the increasing maximum annual pipe strain and ensure pipe safety. A 0.5 m cover of sandbags and coarse rock was placed over the exposed pipe segment. Continued pipe elevation monitoring and annual Geopig surveys have indicated that both seasonal heave/settlement and strains have been reduced subsequent to the remedial loading. Introduction of a gravel berm has also altered both the surrounding hydrologic and ground thermal regimes.
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Berg, Monique, and Shadie S. Radmard. "The Evolution of Facilities Integrity Management at Enbridge Pipelines Inc." In 2012 9th International Pipeline Conference. American Society of Mechanical Engineers, 2012. http://dx.doi.org/10.1115/ipc2012-90730.
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Public and employee safety, environmental stewardship, increased focus by the regulators, public awareness are some of the reasons why operators need to focus on the integrity of their operations and create solutions to reduce common types of releases. In the past, the focus has been on mainline piping integrity due to the greater consequence of mainline releases but increasing importance is being placed on facilities, such as tank terminals and pump stations. Facilities Integrity Management of a pipeline system is a relatively new concept for many companies; however, it is gaining momentum, particularly with regulators and the public. Prior to 2004, various Enbridge departments were responsible for ensuring integrity was maintained within facilities. There was a renewed emphasis and on Enbridge’s Facilities Integrity Programs in 2004 with a mandate of reducing facility releases across the Enbridge Pipeline system. In 2005, a small team of engineers drafted a six-page Facilities Integrity Management System document and program documentation to address facilities integrity issues. Today, Facilities Integrity is responsible for more facilities and programs than originally envisioned. The Integrity Management System documentation has since been amended several times and reviewed through internal and external audits. The Facilities Integrity Management System is vital to the success of the various facilities integrity programs as it identifies responsibilities and associated overlaps and gaps as well as the need for documentation and tracking. As there are no set regulations specific to Facilities Integrity, Enbridge has taken the initiative to be at the forefront of industry practice. This paper will describe Enbridge’s Facilities Integrity Management System: past and present Facilities Integrity programs, current scope of work, the role of Facilities Integrity, the importance of historical release information and program trending, and future initiatives.
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Morrison, Tom, Naurang Mangat, Guy Desjardins, and Arti Bhatia. "Validation of an In-Line Inspection Metal Loss Tool." In 2000 3rd International Pipeline Conference. American Society of Mechanical Engineers, 2000. http://dx.doi.org/10.1115/ipc2000-201.
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Enbridge Pipelines Inc. (“Enbridge”), together with U.S. affiliate Lakehead Pipe Line, operates the world’s longest crude oil and petroleum products pipeline system. These companies transport liquid hydrocarbons from their point of supply to refining markets in the Midwestern United States and Eastern Canada.
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Carroll, L. Blair, and Moe S. Madi. "Crack Detection Program on the Cromer to Gretna, Manitoba Section of Enbridge Pipelines Inc. Line 3." In 2000 3rd International Pipeline Conference. American Society of Mechanical Engineers, 2000. http://dx.doi.org/10.1115/ipc2000-186.
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Enbridge Pipelines Inc. Line 3 is an 860mm (34 inch), API 5LX Grade X52 pipeline with nominal wall thickness ranging from 7.14 mm to 12.5 mm. The Canadian portion of the Line runs from Edmonton, Alberta to Gretna, Manitoba. It was constructed between 1963 and 1969 in a series of loops designed to increase the capacity of the Enbridge system. Until 1999 the pipeline operated in a looped configuration with neighboring 24 inch and 48 inch pipelines. Line 3 downstream of Kerrobert, Saskatchewan began operating in straight 34 inch configuration in 1999 following completion of the first phase expansion project known as Terrace Expansion Project that connects the (48 inch) loops with a new (36 inch) pipeline. In 1997, the Pipetronix (now PII) Ultrascan CD in-line inspection tool was run for 283 km from Cromer to Gretna, Manitoba, to identify long seam cracking and pipe body stress corrosion cracking. This section of the line is comprised primarily of pipe manufactured with a double submerged arc welded long seam with short sections of pipe having electric resistance welded long seams. There were two primary objectives set forth in this inspection project. The first was to assess the integrity of this section of Line 3 and identify anomalies, which might affect the future operation of the pipeline. The second objective was to evaluate the performance of the Ultrascan CD tool and determine its potential role in the Enbridge integrity program. A series of excavations have been conducted based upon the analysis of this data and none of the indications identified were considered to be an immediate concern to the integrity of the pipeline. Notably, two of the excavations resulted in the detection of the first two “significant” SCC colonies (based upon the CEPA definition of significant) [1] found on the Enbridge system. This paper will focus on the tool performance requirements established by Enbridge prior to the inspection run which include specific defect type and size and defects at a maximum sensitivity of the tool. In addition, the information obtained as a result of the excavation program and onsite inspection and assessments. The information gathered, from this program were useful in better understanding the tool tolerance in detecting such defects and to better differentiate between them.
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Haider, Syed J., Steven Textor, Aaron Sutton, and Yvan Hubert. "Managing a New Pressure Cycling Reality in Liquid Pipelines." In 2014 10th International Pipeline Conference. American Society of Mechanical Engineers, 2014. http://dx.doi.org/10.1115/ipc2014-33485.
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Pressure cycling is one of the many operational factors a liquids pipeline company has to contend with in their pipeline integrity cracking program. The management of pressure cycling is important because of the potential development and growth of cracks in the pipe wall by fatigue mechanism where pressure cycling acts as the driving force. The operational source of these cycles can be complex but often include planned start/stops, batch pigs passing pump stations, mid-point injections or deliveries, viscosity changes due to commodity transitions, flow rate changes, and unplanned line outages. The first step to understanding pressure cycling is the development of a methodology which defines pressure cycling targets and monitors cycling on the line. Enbridge Pipelines Inc. (Enbridge) has developed two processes to manage pressure cycling on existing and future assets. These procedures help define the path to limiting pressure cycling but also steer the cultural change required to mitigate this risk within an established operating environment. All operational lines within Enbridge Pipelines Inc. are monitored monthly for pressure cycling risks. Understanding the impact of pressure cycling on these lines can be very complex. To determine the risks associated with an operating pipeline the line’s susceptibility to cracking and its pressure cycling severity must be understood. Once the risks are identified, a pressure cycling mitigation plan, to ensure continued safe operation of the asset can be developed. In order to complete a mitigation plan a detailed operational review needs to be conducted and a company-wide team engaged. The team will determine how the existing operational philosophy can change or what physical modifications are required to improve the current operation and limit or reduce pressure cycling. All new projects within Enbridge have to meet the “Fatigue Design Standard for New Pipelines” to ensure the new line has been designed to handle the estimated cycling. To estimate the cycling of a new line the operational philosophy needs to be well understood; this includes: injection/delivery points, planned maintenance outages, estimated unplanned outages, commodity transitions, transient mitigation, and pressure profiles for each known event. This paper will focus on the processes Enbridge uses to manage pressure cycling on new and existing lines. A separate paper from Enbridge titled “IPC2014-33566: Allowable Pressure Cycling Limits for Pipelines” focuses on the fatigue science and how the pressure cycling targets are determined for the pipelines.
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Desjardins, Guy, Arti Bhatia, and Tom Morrison. "Development and Remote Access of an In-Line Inspection and Corrosion Growth Database." In 2000 3rd International Pipeline Conference. American Society of Mechanical Engineers, 2000. http://dx.doi.org/10.1115/ipc2000-154.
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This paper outlines the development of the Goliath database and its access through the Internet. Goliath is the corrosion and corrosion-rate database developed by Morrison Scientific Inc. (“MSI”) in 1998 and 1999, for Enbridge Pipelines Inc. (“Enbridge”). Its original design and implementation were for the management of corrosion data from in-line inspections and the corrosion-rate analysis results. In addition, Goliath also contains other related data such as pipe parameters, inspection dates, and vendor-company information.
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Chorney, Terris, and Denise Hamsher. "The Evolution of Risk Management at Enbridge Pipelines." In 2000 3rd International Pipeline Conference. American Society of Mechanical Engineers, 2000. http://dx.doi.org/10.1115/ipc2000-100.
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1999 marks an important anniversary for Enbridge Pipelines Inc. of Canada and its U.S.-based affiliate, the Lakehead Pipe Line Company Ltd.: for 50 years we have been the primary link between the large oil production areas of western Canada and major market hubs in the U.S. midwest and eastern Canada. In retrospect, this strong history of success is chiefly due to thorough and logical planning and choice selection in all aspects of company endeavors. At Enbridge, as in countless other firms in a wide-range of industries, decision making was often the product of expert consensus and years of solid experience in dealing with similar situations. This approach has worked well for Enbridge and our stakeholders for five decades, as evidenced by the reliability, efficiency, and safety record of our pipeline system. However, as the millenium nears, we are increasingly finding formalized processes that integrate quantitative models and qualitative analysis helpful in planning and execution for both the short- and long-term. Several broad trends at the root of this movement include the heightened pace of change; the increasingly complex web of relevant factors; the growing magnitude of the consequences associated with sub-optimal decisions; the need for thorough documentation; and the apparent benefits of a framework that enables objectivity and consistency. In short, an approach that completely and systematically evaluates the multitude of dynamic factors that affect the ultimate outcome of the matter at issue is necessary. Although the term “risk management” is now often used to describe this process, Enbridge — along with many other responsible firms in the pipeline operating and other industries — has always practiced the underlying principles. This paper addresses the background of “risk management” in both the Canadian and U.S. pipeline industry, as well as accepted theory. It also encompasses the progression of risk management at Enbridge Pipelines, up to and including current initiatives. The usefulness of risk analysis, risk assessment, and risk management tools will be discussed, along with the overriding necessity of a well thought-out process, firm corporate commitment, and qualified expertise. Much of the focus will address the ongoing evolution and maturity of a comprehensive and well-integrated risk management program within the Enbridge North American business units. The criticality of maintaining focus on the core business function — in this case, pipeline operations — will also be addressed. In addition, past learning’s as well as future opportunities and challenges will be reviewed.
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Song, Peter, Doug Lawrence, Sean Keane, Scott Ironside, and Aaron Sutton. "Pressure Cycling Monitoring Helps Ensure the Integrity of Energy Pipelines." In 2010 8th International Pipeline Conference. ASMEDC, 2010. http://dx.doi.org/10.1115/ipc2010-31394.
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Liquids pipelines undergo pressure cycling as part of normal operations. The source of these fluctuations can be complex, but can include line start-stop during normal pipeline operations, batch pigs by-passing pump stations, product injection or delivery, and unexpected line shut-down events. One of the factors that govern potential growth of flaws by pressure cycle induced fatigue is operational pressure cycles. The severity of these pressure cycles can affect both the need and timing for an integrity assessment. A Pressure Cycling Monitoring (PCM) program was initiated at Enbridge Pipelines Inc. (Enbridge) to monitor the Pressure Cycling Severity (PCS) change with time during line operations. The PCM program has many purposes, but primary focus is to ensure the continued validity of the integrity assessment interval and for early identification of notable changes in operations resulting in fatigue damage. In conducting the PCM program, an estimated fatigue life based on one month or one quarter period of operations is plotted on the PCM graph. The estimated fatigue life is obtained by conducting fatigue analysis using Paris Law equation, a flaw with dimensions proportional to the pipe wall thickness and the outer diameter, and the operating pressure data queried from Enbridge SCADA system. This standardized estimated fatigue life calculation is a measure of the PCS. Trends in PCS overtime can potentially indicate the crack threat susceptibility the integrity assessment interval should be updated. Two examples observed on pipeline segments within Enbridge pipeline system are provided that show the PCS change over time. Conclusions are drawn for the PCM program thereafter.